U.S. patent application number 15/413547 was filed with the patent office on 2018-07-26 for systems and methods for determining a root cause of an issue in an electrical grid.
The applicant listed for this patent is Southern Company. Invention is credited to Joshua Ashcraft, Mitch A. Cason, Wesley M. Granade, Tommy Jamison, Jr., Robert D. King, Brandon Lundy, Jamie R. Meaders, Ravikanth C. Paruchuri, Derl W. Rhoades.
Application Number | 20180210038 15/413547 |
Document ID | / |
Family ID | 62906952 |
Filed Date | 2018-07-26 |
United States Patent
Application |
20180210038 |
Kind Code |
A1 |
King; Robert D. ; et
al. |
July 26, 2018 |
SYSTEMS AND METHODS FOR DETERMINING A ROOT CAUSE OF AN ISSUE IN AN
ELECTRICAL GRID
Abstract
An exemplary embodiment of the present invention provides a
method for determining root causes of issues in an electrical grid.
The method includes receiving local data from each of a plurality
of meters. The local data may be indicative of voltage levels
measured by the plurality of meters. The method also includes
identifying abnormalities in the received local data. An
abnormality is indicated by local data indicative of a voltage
level that is outside of a predetermined range of acceptable
levels. The method further includes associating each of the
identified abnormalities with a respective meter and a geographic
location of the respective meter and analyzing each of the
identified abnormalities according to a predetermined set of
evaluation factors to determine a root cause.
Inventors: |
King; Robert D.; (Atlanta,
GA) ; Ashcraft; Joshua; (Atlanta, GA) ;
Meaders; Jamie R.; (Atlanta, GA) ; Jamison, Jr.;
Tommy; (Atlanta, GA) ; Paruchuri; Ravikanth C.;
(Atlanta, GA) ; Granade; Wesley M.; (Atlanta,
GA) ; Cason; Mitch A.; (Atlanta, GA) ;
Rhoades; Derl W.; (Birmingham, AL) ; Lundy;
Brandon; (Birmingham, AL) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
Southern Company |
Atlanta |
GA |
US |
|
|
Family ID: |
62906952 |
Appl. No.: |
15/413547 |
Filed: |
January 24, 2017 |
Current U.S.
Class: |
1/1 |
Current CPC
Class: |
G01R 31/40 20130101;
G01R 19/04 20130101; G01R 31/088 20130101; G06Q 50/06 20130101 |
International
Class: |
G01R 31/40 20060101
G01R031/40; G01R 19/04 20060101 G01R019/04 |
Claims
1. A method for determining root causes of issues in an electrical
grid comprising: receiving, from each of a plurality of meters,
local data, the local data indicative of voltage levels measured by
the plurality of meters; identifying abnormalities in the received
local data, wherein an abnormality is indicated by local data
indicative of a voltage level that is outside of a predetermined
range of acceptable levels; associating each of the identified
abnormalities with a respective meter and a geographic location of
the respective meter; and analyzing each of the identified
abnormalities according to a predetermined set of evaluation
factors to determine a root cause.
2. The method of claim 1, wherein each meter transmits local data
that the meter recorded over a specified time period, the local
data comprising a maximum voltage value, a minimum voltage value,
and an average voltage value.
3. The method of claim 2, wherein analyzing each of the identified
abnormalities according to the predetermined set of evaluation
factors comprises: identifying whether each of the identified
abnormalities is associated with a maximum voltage value, a minimum
voltage value, and/or an average voltage value; identifying a
severity and duration of each of the identified abnormalities; and
associating each of the identified abnormalities from a particular
meter in the plurality of meters with each of the identified
abnormalities from other meters in the plurality of meters in a
predetermined geographic vicinity, wherein the predetermined
geographic vicinity is predetermined by geography and a layout of
an electrical grid.
4. The method of claim 1, further comprising filtering out false
positive values by limiting identification of the root cause to
only those abnormalities that exist for at least a predetermined
time requirement.
5. The method of claim 2, wherein the local data is further
indicative of a model of each of the plurality of meters, and the
root cause is a meter that requires replacement if the model of the
meter is outdated.
6. The method of claim 3, wherein the root cause is a meter that
requires reprogramming if the average voltage value transmitted by
the meter is not between the minimum voltage value and maximum
voltage value transmitted by the meter.
7. The method of claim 3, wherein the root cause is voltage
supplied from a transmission line to a pole- or pad-mount
substation if at least predetermined number or percentage of meters
reporting abnormalities are served from a point that does not
provide voltage regulation.
8. The method of claim 3, wherein the root cause is a
malfunctioning transformer if at least a predetermined number or
percentage of the meters serviced by a particular transformer
experience an abnormality.
9. The method of claim 3, wherein the root cause is a
malfunctioning voltage regulating device if at least a first
predetermined number of transformers service at least a second
predetermined number of meters that experience an abnormality.
10. The method of claim 3, wherein the root cause is impending
failure of a transformer if at least a predetermined number or
percentage of a plurality of meters experiences a sudden increase
in voltage by at least a predetermined amount, wherein each of the
plurality of meters is serviced by the same transformer.
11. The method of claim 3, wherein the root cause is use of an
incorrect meter type if a meter experiences a voltage that is
outside a predetermined range of acceptable values.
12. The method of claim 3, wherein the root cause is inappropriate
socket wiring if a meter experiences a consistent voltage that is
outside the predetermined range of acceptable values and the meter
is of the correct type of meter required.
13. The method of claim 3, wherein the root cause is an open or
failing secondary or service conductor or connection if one or more
meters experiences a sudden decrease in voltage by at least a
predetermined amount, wherein each of the meters is serviced by the
same transformer.
14. The method of claim 3, wherein each meter has a transformer
distance, the transformer distance being a distance between a meter
and a transformer that services the meter; and wherein the root
cause is an undersized service conductor if there is a correlation
between the transformer distances of meters serviced by a
particular transformer and a decrease in voltage in at least some
of the meters, wherein the decrease in voltage is at least a
predetermined percentage below a desired minimum voltage value.
15. The method of claim 3, wherein the root cause is an undersized
service conductor if at least some meters serviced by a particular
transformer experience a voltage decrease that is at least a
predetermined percentage below a desired minimum voltage value
during a high-use period of time, wherein the high-use period of
time is defined as a duration of time during which the voltage
decrease is experienced by at least a predetermined percentage of
the meters, the voltage decrease occurring on a regular basis and
occurring at least a predetermined number of times.
16. The method of claim 3, wherein the root cause is a
malfunctioning regulator on a particular phase if the abnormalities
in a predetermined geographic area are experienced by at least a
predetermined number of meters that are on a same phase.
17. A system comprising: a processor; and a non-transitory
computer-readable medium that stores instructions that, when
executed by a processor of a computing device, cause the processor
to: receive local data transmitted from a plurality of meters in an
electrical grid; identify abnormalities in the received local data,
wherein an abnormality is indicated by local data indicative of a
voltage level that is outside of a predetermined range of
acceptable levels; associate each of the identified abnormalities
with a respective meter and a geographic location of the respective
meter; and analyze the identified abnormalities according to a
predetermined set of evaluation factors to determine a root
cause.
18. The system of claim 17, wherein the non-transitory
computer-readable medium further stores instructions that, when
executed by the processor, cause the processor to issue a work
order to an appropriate technician based on the root cause.
19. The system of claim 17, wherein the computing device is
operatively connected to a display displaying a map identifying
devices of the electrical grid including conductors, transformers,
capacitors, regulators, and meters.
20. The system of claim 19, wherein the map identifies the location
of devices identified as reporting abnormalities in relationship to
devices that have been determined to be a root cause for an
identified abnormality.
Description
TECHNICAL FIELD OF THE INVENTION
[0001] The various embodiments of the present disclosure relate
generally to determining a cause of an issue in an electrical grid.
More particularly, the various embodiments of the present invention
are directed to identifying and diagnosing an issue, or a potential
issue, in an electrical grid.
BACKGROUND OF THE INVENTION
[0002] Electrical utilities are required to adhere to standards set
by various regulatory entities, including public service
commissions, public utility commissions, and industry standards.
Some of these standards address an optimal service voltage. To
measure service voltage, electrical utilities commonly use meters
at customer locations, as well as Advanced Metering Infrastructure
("AMI"), which allows a utility to remotely read and control
meters. Electrical utilities face several challenges in meeting
these regulatory standards including a huge number of meters and an
even larger amount of data associated with the values measured by
each meter, which can number in the hundreds of millions of data
points per weeks. Due to the massive number of voltage readings,
inspection of each out-of-range reading by a meter would be
impractical, if not impossible. Additionally, existing practices
used by electrical utilities generally require a technician to
manually inspect a problematic meter, as well as the electrical
grid in the near vicinity of the problematic meter. This is because
several components of the electrical grid can affect the voltage
readings of meters.
[0003] Electrical devices within an electrical grid are designed to
operate within particular voltage ranges; operation outside of
these designated voltage ranges may be detrimental to an electrical
device, causing the device to operate less efficiently, age faster,
or even fail. Some devices may fail for other reasons, such as a
device that has outlived its useful life. Regardless, a failure of
an electrical device or some other non-functionality within the
electrical grid may cause localized or wide-spread power loss to
customers.
[0004] Furthermore, electrical utilities commonly employ multiple
types of technicians, who possess different skill levels and are
outfitted with different tools. Electrical utilities frequently
assign particular tasks to a given technician depending on the
issue that requires attention and the type of technician. A
technician sent to inspect a meter that has reported an
out-of-range voltage may find that he or she does not have the
correct tools or expertise for the issue causing the out-of-range
readings at the meter. The electrical utility may then be required
to send a second technician to correct the issue. This inefficiency
can prove costly in terms of resources and money for an electrical
utility. Additional expense can be incurred by an electrical
utility due to false positives, which may be reported by some
meters.
[0005] Moreover, existing practices of electrical utilities
generally require an electrical device to fail before it can be
identified and repaired or replaced. This may cause a power loss
for customers.
[0006] Therefore, there is a desire for a method and system to
identify and diagnose an issue in an electrical grid without
manually inspecting individual meters. There is a further desire
for a method and system to identify and diagnose an issue in an
electrical grid prior to its occurrence, such that the issue may be
repaired prior to causing a power loss to customers. Various
embodiments of the present invention address these desires.
BRIEF SUMMARY OF THE INVENTION
[0007] The present invention relates to identifying and diagnosing
an issue in an electrical grid with the use of data recorded by a
plurality of meters within the electrical grid. An exemplary
embodiment of the present invention provides a method for
determining root causes of issues in an electrical grid. The method
may include receiving, from each of a plurality of meters, local
data that is indicative of voltage levels measured by the plurality
of meters, and identifying abnormalities in the received local
data. An abnormality may be indicated by local data indicative of a
voltage level that is outside of a predetermined range of
acceptable levels. The method may also include associating each of
the identified abnormalities with a respective meter and a
geographic location of the respective meter, and analyzing each of
the identified abnormalities according to a predetermined set of
evaluation factors to determine a root cause.
[0008] In certain embodiments, each meter may transmit local data
that the meter recorded over a specified time period, and the local
data can include a maximum voltage value, a minimum voltage value,
and an average voltage value.
[0009] In some embodiments, analyzing each of the identified
abnormalities according to the predetermined set of evaluation
factors includes identifying whether each of the identified
abnormalities is associated with a maximum voltage value, a minimum
voltage value, and/or an average voltage value; identifying a
severity and duration of each of the identified abnormalities; and
associating each of the identified abnormalities from a particular
meter in the plurality of meters with each of the identified
abnormalities from other meters in the plurality of meters in a
predetermined geographic vicinity. The predetermined geographic
vicinity may be predetermined by geography and a layout of an
electrical grid.
[0010] In some embodiments, the method may also include filtering
out false positive values by limiting identification of the root
cause to only those abnormalities that exist for at least a
predetermined time requirement.
[0011] In certain embodiments, the local data may be further
indicative of a model of each of the plurality of meters, and the
root cause may be a meter that requires replacement if the model of
the meter is outdated.
[0012] In some embodiments, the root cause may be a meter that
requires reprogramming if the average voltage value transmitted by
the meter is not between the minimum voltage value and maximum
voltage value transmitted by the meter.
[0013] In some embodiments, the root cause may be voltage supplied
from a transmission line to a pole- or pad-mount substation if a
plurality of meters reporting abnormalities is served from a point
that does not provide voltage regulation.
[0014] In some embodiments, the root cause may be a malfunctioning
transformer if at least a predetermined percentage of the meters
serviced by a particular transformer experience an abnormality.
[0015] In certain embodiments, the root cause may be a
malfunctioning voltage regulating device if at least a first
predetermined number of transformers service at least a second
predetermined number of meters that experience an abnormality.
[0016] In some embodiments, the root cause may be impending failure
of a transformer if a plurality of meters experiences a sudden
increase in voltage by at least a predetermined amount and if each
of the plurality of meters is serviced by the same transformer.
[0017] In some embodiments, the root cause may be use of an
incorrect meter type if a meter experiences a voltage that is
outside a predetermined range of acceptable values.
[0018] In certain embodiments, the root cause may be inappropriate
socket wiring if a meter experiences a consistent voltage that is
outside the predetermined range of acceptable values and the meter
is of the correct type of meter required.
[0019] In some embodiments, the root cause may be an open or
failing secondary or service conductor or connection if one or more
meters experiences a sudden decrease in voltage by at least a
predetermined amount and if each of the meters is serviced by the
same transformer.
[0020] In certain embodiments, each meter can have a transformer
distance, which is the distance between a meter and the transformer
that services the meter. The root cause may be an undersized
service conductor if there is a correlation between the transformer
distances of meters serviced by a particular transformer and a
decrease in voltage in at least some of the meters, and if the
decrease in voltage is at least a predetermined percentage below a
desired minimum voltage value.
[0021] In some embodiments, the root cause may be an undersized
service conductor if at least some meters serviced by a particular
transformer experience a voltage decrease that is at least a
predetermined percentage below a desired minimum voltage value
during a high-use period of time. The high-use period of time may
be defined as a duration of time during which the voltage decrease
is experienced by at least a predetermined percentage of the
meters, occurs on a regular basis, and occurs at least a
predetermined number of times.
[0022] In some embodiments, the root cause may be a regulator on a
particular phase if the abnormalities in a predetermined geographic
area are experienced by at least a predetermined number of meters
that are on a same phase.
[0023] An exemplary embodiment of the present invention provides a
system that includes a processor and a non-transitory
computer-readable medium that stores instructions. When executed by
a processor of a computing device, the instructions may cause the
processor to receive local data transmitted from a plurality of
meters in an electrical grid and identify abnormalities in the
received local data. An abnormality may be indicated by local data
indicative of a voltage level that is outside of a predetermined
range of acceptable levels. The instructions may further cause the
processor to associate each of the identified abnormalities with a
respective meter and a geographic location of the respective meter
and analyze the identified abnormalities according to a
predetermined set of evaluation factors to determine a root
cause.
[0024] In certain embodiments, the non-transitory computer-readable
medium may also stores instructions that, when executed by the
processor, cause the processor to issue a work order to an
appropriate technician based on the root cause.
[0025] In some embodiments, the computing device may be operatively
connected to a display displaying a map that may identify devices
of the electrical grid including conductors, transformers,
capacitors, regulators, and meters.
[0026] In some embodiments, the map may identify devices that have
been determined to be a root cause for an identified
abnormality.
[0027] These and other aspects of the present invention are
described in the Detailed Description of the Invention below and
the accompanying figures. Other aspects and features of embodiments
of the present invention will become apparent to those of ordinary
skill in the art upon reviewing the following description of
specific, exemplary embodiments of the present invention in concert
with the figures. While features of the present invention may be
discussed relative to certain embodiments and figures, all
embodiments of the present invention can include one or more of the
features discussed herein. Further, while one or more embodiments
may be discussed as having certain advantageous features, one or
more of such features may also be used with the various embodiments
of the invention discussed herein. In similar fashion, while
exemplary embodiments may be discussed below as device, system, or
method embodiments, it is to be understood that such exemplary
embodiments can be implemented in various devices, systems, and
methods of the present invention.
BRIEF DESCRIPTION OF THE DRAWINGS
[0028] The following Detailed Description of the Invention is
better understood when read in conjunction with the appended
drawings. For the purposes of illustration, there is shown in the
drawings exemplary embodiments, but the subject matter is not
limited to the specific elements and instrumentalities
disclosed.
[0029] FIG. 1 provides a graphical depiction of a sudden voltage
abnormality, as recorded by a meter, in accordance with an
exemplary embodiment of the present invention.
[0030] FIG. 2 provides a graphical depiction of a gradual voltage
abnormality, as recorded by a meter, in accordance with an
exemplary embodiment of the present invention.
[0031] FIG. 3 provides a graphical user interface of a computer
system depicting a map with an electrical grid overlay, in
accordance with an exemplary embodiment of the present
invention.
[0032] FIG. 4 provides a graphical depiction of average voltage,
maximum voltage, and minimum voltage values, as recorded by a meter
operating within a generally acceptable voltage range, in
accordance with an exemplary embodiment of the present
invention.
[0033] FIG. 5 provides a graphical user interface of average
voltage, maximum voltage, and minimum voltage values, as recorded
by a meter with an excursion outside a generally acceptable voltage
range, in accordance with an exemplary embodiment of the present
invention.
DETAILED DESCRIPTION OF THE INVENTION
[0034] To facilitate an understanding of the principles and
features of the present invention, various illustrative embodiments
are explained below. To simplify and clarify explanation, the
invention is described below as applied to identifying and
diagnosing an issue in an electrical grid with the use of data
recorded by a plurality of meters within the electrical grid. One
skilled in the art will recognize, however, that the invention is
not so limited.
[0035] The components, steps, and materials described hereinafter
as making up various elements of the invention are intended to be
illustrative and not restrictive. Many suitable components, steps,
and materials that would perform the same or similar functions as
the components, steps, and materials described herein are intended
to be embraced within the scope of the invention. Such other
components, steps, and materials not described herein can include,
but are not limited to, similar components or steps that are
developed after development of the invention.
[0036] Electrical utilities maintain electrical grids that commonly
include millions of meters. Depending on the frequency with which
each meter is programmed to transmit the values it has recorded,
electrical utilities can be inundated with hundreds of millions of
data points per week. Properly interpreted, these data points can
be used to identify individual electrical devices within the
electrical grid that have failed and require corrective maintenance
or are nearing failure and require preventative maintenance.
Therefore, electrical utilities would benefit from a method or
system that can evaluate a large amount of data, identify any
abnormalities in the data, and accurately diagnose any issues
associated with any abnormalities, such that corrective or
preventative maintenance may be completed. Further, customers of
electrical utilities would also benefit, in that customers would be
less likely to incur a power loss should such a method or system be
implemented.
[0037] Some embodiments of the disclosed technology include novel
techniques for determining root causes of issues in an electrical
grid. According to certain embodiments, local data, which is
measured by each of a plurality of meters within the electrical
grid, is received. The local data can include a maximum voltage, a
minimum voltage, and an average voltage. In some embodiments, the
local data includes other information pertaining to electricity,
such as current. In some embodiments, the local data includes
information regarding the meter itself, such as a model number for
a particular meter. In some embodiments, meters record
instantaneously occurring data a predetermined number of times per
day. In some embodiments, meters transmit recorded data a
predetermined number of times per day. In some embodiments, the
transmitted data may represent the whole of a specified time
period. For instance, a meter might record data every 15 minutes
and might transmit the recorded data four times per day. Continuing
this example, one instance of transmitted data might represent a
six-hour period that occurs between transmissions by the meter. In
certain embodiments, data may be recorded and/or transmitted on an
hourly basis. In some embodiments, as few as a single data
transmission may be transmitted by a meter during a predetermined
time interval; certain embodiments may allocate the transmitted
measurement values (e.g., average, maximum, and minimum voltage
values) to represent the entire predetermined time interval for the
purposes of analysis and/or identification of abnormalities. For
example, if a meter is configured to transmit one transmission
every six hours, certain embodiments may allocate the data of a
single transmission to represent any and/or all times during the
respective six-hour period.
[0038] It is to be understood that any frequency of data recording
by the meters is herein contemplated. Similarly, any frequency of
transmission of recorded data by the meters is also herein
contemplated. Frequency of recordings and transmissions may be
adjusted depending on the level of specificity desired. Increased
frequency may result in data that more closely resembles the actual
values experienced at a meter but will also increase the amount of
resultant data. Decreased frequency may result in data that less
closely resembles the actual values experienced at a meter but will
decrease the amount of resultant data, making management of the
data more manageable. There may be recording and transmission
frequencies that sufficiently reflect the actual values experienced
at the meter, while providing a minimal amount of data, thus
increasing the ease of data management.
[0039] According to certain embodiments, identification of
abnormalities in the received local data may be made. An
abnormality may be indicated by local data indicative of a voltage
level that is outside of a predetermined range of acceptable
levels. In some embodiments, an association of each identified
abnormality with a respective meter may be made. In some
embodiments, an association of each identified abnormality with a
geographic location of the respective meter may also be made.
[0040] In certain embodiments, analysis of each of the identified
abnormalities may be performed according to a predetermined set of
evaluation factors. In some embodiments, this step includes
identifying whether each of the identified abnormalities is
associated with a maximum voltage value, a minimum voltage value,
and/or an average voltage value. In some embodiments, this step
includes identifying a severity and duration of each of the
identified abnormalities. In some embodiments, this step includes
associating each of the identified abnormalities from a particular
meter with each of the identified abnormalities in nearby meters
with respect to geospatial location of the meters with respect to
one another, as well as the location of the meters with respect to
one another within the electrical grid.
[0041] Some embodiments may include a filtering function, which can
filter out false positive values that may be triggered due to
normal fluctuations in voltages within the electrical grid. In some
embodiments, a filtering function may limit identification of a
root cause to only those abnormalities that exist for at least a
predetermined percentage of time. In some embodiments, a filtering
function may limit identification of a root cause to only those
abnormalities that occur for at least a predetermined number of
times. It should be noted that throughout this disclosure,
including the claims, requirements with respect to the frequency of
an abnormality occurring includes both (i) the existence of the
abnormality for at least a predetermined percentage of time within
a specified time period (which may be a rolling time period) and
(ii) an abnormality that occurs at least a predetermined number of
times.
[0042] In certain embodiments, the root cause may be identifiable
from the local data of a single meter. For instance, local data may
indicate that a meter reporting an abnormality is a legacy device,
i.e., the model of that particular meter is outdated. Thus, the
root cause may be resolved by replacing the outdated meter with a
current model of meter.
[0043] In some embodiments, the root cause may be identified as a
meter that requires reprogramming if a meter reports an average
voltage value that is not between the reported minimum voltage
value and the reported maximum voltage value.
[0044] In certain embodiments, the root cause may be identifiable
by relating values reported by a meter to values reported by other
meters. For instance, the root cause may be identified as voltage
supplied from a transmission line to a pole- or pad-mount
substation if at least predetermined number or percentage of meters
that are reporting abnormalities are served from a point that does
not provide voltage regulation.
[0045] In some embodiments of the present invention, a
predetermined number or percentage of the meters serviced by the
same transformer experiencing an abnormality is indicative of a
root cause being a malfunctioning transformer. For example, in some
embodiments of the invention, multiple meters serviced by the same
transformer experiencing an abnormality is indicative of a root
cause being a malfunctioning transformer. In some embodiments, 1,
2, 3, 4, 5, or more meters serviced by the same transformer
experiencing an abnormality is indicative of a root cause being a
malfunctioning transformer. In some embodiments, 10%, 15%, 20%,
25%, 30%, 35%, 40%, 45%, 50%, 55%, 60%, 65%, 70%, 75%, or more
meters serviced by the same transformer experiencing an abnormality
is indicative of a root cause being a malfunctioning
transformer.
[0046] In certain embodiments, a transformer may soon fail if at
least a predetermined number or percentage or number of meters
serviced by a transformer experience a sudden increase in voltage.
In some embodiments, meters must experience a sudden increase in
voltage by at least a predetermined amount in order for a root
cause of a failing transformer to be identified. A graphical
depiction of the values recorded by a meter serviced by a failing
transformer is shown in FIG. 5. For the purpose of comparison, a
graphical depiction of generally normal values recorded by a meter
is shown in FIG. 4. In some embodiments, 1, 2, 3, 4, 5, or more
meters serviced by the same transformer experiencing a sudden
increase in voltage is indicative of a transformer nearing failure.
In some embodiments, 10%, 15%, 20%, 25%, 30%, 35%, 40%, 45%, 50%,
55%, 60%, 65%, 70%, 75%, or more meters serviced by the same
transformer experiencing a sudden increase in voltage is indicative
of a transformer nearing failure.
[0047] In some embodiments, the root cause may be identified as a
malfunctioning voltage regulation device if at least a
predetermined number or percentage of transformers service at least
a predetermined number or percentage of meters experiencing an
abnormality. In some embodiments, the number or percentage of
transformers may be relatively high, and the number or percentage
of meters experiencing an abnormality may be relatively low. For
instance, a large number of transformers, such as 5, 10, or more,
may each service as few as a single meter that is experiencing an
abnormality. In some embodiments, the number or percentage of
transformers may be relatively low, and the number or percentage of
meters experiencing an abnormality may be relatively high. For
instance, few transformers, such as 2, 3, 4, or more transformers,
may each service a plurality of meters, and at least 1%, 2%, 5%,
10% or more of the plurality corresponding to each of the few
transformers experiences an abnormality.
[0048] In certain embodiments, an incorrect meter type may be in
use if a meter experiences a consistent voltage that is outside of
a predetermined range of acceptable values.
[0049] In some embodiments, inappropriate socket wiring may be
identified as the root cause if a meter experiences a consistent
voltage that is outside of a predetermined range of acceptable
values and the meter is of the correct type of meter required.
[0050] In some embodiments, the root cause may be an open or
failing secondary or service conductor or connection if one or more
meters that are serviced by the same transformer experiences a
sudden decrease in voltage by at least a predetermined amount.
[0051] In certain embodiments, each meter may be assigned a
transformer distance, which is the distance between a meter and the
transformer that services the meter. The root cause may, in some
embodiments, be an undersized service conductor if there is a
correlation between the transformer distances of meters serviced by
a particular transformer and a decrease in voltage in at least some
of the meters serviced by that transformer. The decrease in voltage
may be at least a predetermined amount or percentage below a
desired minimum voltage value.
[0052] In some embodiments, the root cause may be a malfunctioning
regulator on a particular phase if the abnormalities in a
predetermined geographic area or a predetermined portion of the
electrical grid are experienced by at least a predetermined number
or percentage of meters that are on the same phase. In some
embodiments, 3, 4, 5, or more meters that are on the same phase
experiencing an abnormality is indicative of a root cause being a
malfunctioning regulator on a particular phase. In some
embodiments, 10%, 15%, 20%, 25%, 30%, 35%, 40%, 45%, 50%, 55%, 60%,
65%, 70%, 75%, or more meters that are on the same phase
experiencing an abnormality is indicative of a root cause being a
malfunctioning regulator on a particular phase.
[0053] According to some embodiments, a system is provided, which
includes a processor and a non-transitory computer readable medium
that stores instructions. In some embodiments, this system is
software saved in memory on a computer. In some embodiments, this
system is saved on a physical disk or other medium. These
instructions, when executed by a processor of a computer or other
computing device, may cause the processor to receive local data
transmitted from a plurality of meters in an electrical grid and
identify abnormalities in the received data. An abnormality, as
explained above, is indicated by local data indicative of a voltage
level that is outside of a predetermined range of acceptable
values. The instructions may also associate each of the identified
abnormalities with a respective meter and a location of the
respective meter. The location may be geographical, with respect to
the electrical grid itself, or both.
[0054] The instructions may also analyze the identified
abnormalities according to a predetermined set of evaluation
factors to determine a root cause. In some embodiments, the
instructions also cause the processor to issue a work order to an
appropriate technician depending on the root cause identified by
the system. This may help to ensure that the correct technician is
dispatched the first time, which may mitigate or eliminate waste of
money and resources that is caused by dispatching an incorrect
technician.
[0055] In certain embodiments, the computing device is operatively
connected to a display the can display a map that can identify
devices of the electrical grid. These devices can include
conductors, transformers, capacitors, regulators, and meters. In
some embodiments, the map may identify devices that have been
determined to be a root cause for an identified abnormality. This
may be done in a variety of ways including differentiating
problematic devices from other devices by use of different colors,
different symbols or icons, etc. An example of an embodiments
including a map display is shown in FIG. 3.
[0056] In some embodiments, the computing device may generate a
report including the highest priority of identified root causes.
The highest priority of identified root causes may be based on a
number of criteria including monetary cost of the associated device
and number of customers affected by failure of the associated
device.
[0057] In some embodiments, a graphical depiction of readings
received from a particular meter is displayed via the display. As
shown in FIG. 4, in some embodiments, the graphical depiction may
also include related information, such as regulative requirements.
This may aid engineers or other employees of an electrical utility
in manually identifying abnormalities, such as a failing
transformer, an example of which is shown in FIG. 5.
[0058] In some embodiments, the system is configured to provide
daily updates. In some embodiments, updates are provided more
frequently; in some embodiments, updates are provided less
frequently.
[0059] In some embodiments, the system may be configured to
operative in conjunction with existing software and services
commonly used by electrical utilities. These software and services
may include MicrosoftSQL Server Integration Services; AMI; Esri
Geographic Information Systems; maps services, such as Google Maps
or Bing Maps; and Datazen.
[0060] It is to be understood that the embodiments and claims
disclosed herein are not limited in their application to the
details of construction and arrangement of the components set forth
in the description and illustrated in the drawings. Rather, the
description and the drawings provide examples of the embodiments
envisioned. The embodiments and claims disclosed herein are further
capable of other embodiments and of being practiced and carried out
in various ways. Also, it is to be understood that the phraseology
and terminology employed herein are for the purposes of description
and should not be regarded as limiting the claims.
[0061] Accordingly, those skilled in the art will appreciate that
the conception upon which the application and claims are based may
be readily utilized as a basis for the design of other structures,
methods, and systems for carrying out the several purposes of the
embodiments and claims presented in this application. It is
important, therefore, that the claims be regarded as including such
equivalent constructions.
[0062] Furthermore, the purpose of the foregoing Abstract is to
enable the United States Patent and Trademark Office and the public
generally, and especially including the practitioners in the art
who are not familiar with patent and legal terms or phraseology, to
determine quickly from a cursory inspection the nature and essence
of the technical disclosure of the application. The Abstract is
neither intended to define the claims of the application, nor is it
intended to be limiting to the scope of the claims in any way.
Instead, it is intended that the invention be defined by the claims
appended hereto.
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